CN109837074B - Fluid loss additive composition and application thereof, water-based drilling fluid and application thereof - Google Patents
Fluid loss additive composition and application thereof, water-based drilling fluid and application thereof Download PDFInfo
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Abstract
The invention relates to the field of drilling fluid, and discloses a fluid loss additive composition and application thereof, and a water-based drilling fluid and application thereof. Book (I)The fluid loss additive composition provided by the invention comprises a main fluid loss additive and a fluid loss additive; the main filtrate reducer is cellulose graft copolymer, and the auxiliary filtrate reducer is at least one of polymer filtrate reducer GDK, low-viscosity filtrate reducer SDDJ-3, filtrate reducer Redu1, temperature-resistant and salt-resistant filtrate reducer SDKJ-2 and silicofluoride filtrate reducer GF; the cellulose graft copolymer comprises a carboxymethyl cellulose main chain and a side chain, wherein the side chain comprises a structural unit shown in a formula (1), a structural unit shown in a formula (2) and a structural unit shown in a formula (3); the filtrate reducer composition can improve the performances of temperature resistance, salt resistance, calcium resistance, poor soil resistance and the like of the water-based drilling fluid.
Description
Technical Field
The invention relates to the field of drilling fluid, in particular to a fluid loss additive composition and application thereof in water-based drilling fluid, and water-based drilling fluid and application thereof in oil extraction in oil fields.
Background
Along with the development of the petroleum industry and the continuous increase of the petroleum demand, the exploration and development of oil gas are slowly developed towards the middle and deep part, the environmental protection in the oil gas exploration and development is more and more emphasized, the drilling fluid treating agent is an indispensable part in the exploitation process, the requirement on the drilling fluid treating agent is higher and higher, and the problem of improving the safety, the efficiency and the environmental protection performance of the drilling fluid is needed to be solved urgently.
The water-base drilling fluid is a sol-suspension mixed system using water as dispersing medium and clay (bentonite), weighting agent and various chemical treatment agents as dispersing phase. The main components of the agent are water, clay, weighting agent and various chemical treatment agents. The water-based drilling fluid basically goes through five stages, namely, a natural drilling fluid, a finely dispersed drilling fluid, a coarsely dispersed drilling fluid, a non-dispersed low solid phase drilling fluid, a solid phase-free drilling fluid, a polymer drilling fluid stage and the like.
In the drilling fluid treating agent, the filtrate reducer has large dosage and various types, and is mainly natural materials or natural material modified products and synthetic polymers. Natural materials and their modified products include starch, cellulose, vegetable gums, xanthan gum and its derivatives; the synthetic polymer mainly takes reactants of phenolic resin and ethylene propylene monomer which are obtained by condensation polymerization of phenolic monomer and aldehyde monomer. Under specific conditions, inorganic compounds such as superfine calcium carbonate, ceramic dust and the like can be compounded to be used as the fluid loss additive.
In recent years, natural materials have been paid attention to and become one of the important research directions of drilling fluid technology, mainly because of wide sources, low price, convenience for graft modification, environmental protection and easy degradation. The cellulose and modified products in natural polymers gradually replace the traditional drilling fluid treating agent and become one of the most widely used treating agents. Because the main chains of cellulose molecules are connected by ether bonds, the temperature resistance in the drilling fluid can only reach about 120 ℃, and the salt resistance and the calcium pollution resistance of the drilling fluid are limited.
In order to improve the temperature resistance, cellulose is generally subjected to modification treatment in the prior art. Common modifications include: physical modification of cellulose, biological modification of cellulose, and chemical modification of cellulose.
The physical modification of the cellulose means that the particle size of the cellulose is changed under the action of external force without adding any chemical agent, and the properties of the cellulose are changed although the chemical components of the cellulose are not changed.
The biological modification of cellulose mainly means that the cellulose changes the property thereof through biological enzyme, in particular to cellulase, which is mainly applied to the papermaking industry and is multipurpose to the papermaking industry.
The chemical modification of cellulose mainly comprises:
1) esterification and etherification of cellulose
Hydroxyl on cellulose molecules can react with different monomers to generate various cellulose macromolecular polymers such as cellulose ester, cellulose ether and the like.
2) Oxidation of cellulose
Also aiming at the hydroxyl in the cellulose, aldehyde group, carboxyl group and other groups are introduced into the cellulose through oxidation under certain conditions, and the carboxyl cellulose is treated by NaOH to obtain-COONa.
3) Graft copolymerization of cellulose
In order to achieve different performance requirements, corresponding monomer groups are grafted on cellulose molecules, so that new functions are given to the cellulose. Compared with natural cellulose, the modified cellulose has certain improvement on performance, but the relative molecular weight is not changed greatly, so that the improvement on viscosity and strength is greatly influenced.
With the excessive exploitation of oil and gas fields, the external conditions of drilling become more severe and are often carried out in more complex stratums, and the improvement of the temperature resistance, salt resistance, calcium pollution resistance and environmental protection performance of the drilling fluid is a problem to be solved urgently.
Disclosure of Invention
The invention aims to overcome the problems of limited temperature resistance, salt resistance and calcium pollution resistance of the drilling fluid in the prior art, and provides a fluid loss additive composition and application thereof in water-based drilling fluid, and water-based drilling fluid and application thereof in oil extraction in oil fields. The water-based drilling fluid provided by the invention has better temperature resistance, salt resistance, calcium resistance, poor soil resistance and the like.
In order to achieve the above object, the present invention provides in a first aspect a fluid loss additive composition comprising a main fluid loss additive and a fluid loss additive, wherein the main fluid loss additive is a cellulose graft copolymer and the fluid loss additive is at least one selected from the group consisting of a polymer-based fluid loss additive GDK, a low-viscosity fluid loss additive SDDJ-3, a fluid loss additive Redu1, a temperature-resistant and salt-resistant fluid loss additive SDKJ-2, and a silicofluoride-based fluid loss additive GF;
the cellulose graft copolymer comprises a carboxymethyl cellulose main chain and a side chain, wherein the side chain comprises a structural unit shown in a formula (1), a structural unit shown in a formula (2) and a structural unit shown in a formula (3);
the mass ratio of the main chain of the carboxymethyl cellulose to the structural unit shown in the formula (1), the structural unit shown in the formula (2) and the structural unit shown in the formula (3) is (2-6): (1-4): (1-3): 1;
the mass ratio of the main filtrate reducer to the auxiliary filtrate reducer is (0.1-3) to 1.
In a second aspect, the invention provides the use of the fluid loss additive composition in a water-based drilling fluid.
In a third aspect of the invention, there is provided a water-based drilling fluid comprising water, said fluid loss additive composition, a viscosifier, a plugging and anti-sloughing agent, a lubricant, a clay and a weighting agent, and optionally a shale inhibitor.
In a fourth aspect, the invention provides the use of the water-based drilling fluid of the third aspect of the invention in oil recovery in an oil field.
Through the technical scheme, the water-based drilling fluid provided by the invention has the advantages of good temperature resistance, salt resistance, calcium resistance and poor soil resistance, good fluid loss reduction capability, good lubricating property and good sedimentation stability, and can meet the requirement of environmental protection.
Drawings
FIG. 1 is an infrared spectrum of carboxymethyl cellulose;
FIG. 2 is an infrared spectrum of a cellulose graft copolymer A1 prepared in preparation example 1 of the present invention.
Detailed Description
The endpoints of the ranges and any values disclosed herein are not limited to the precise range or value, and such ranges or values should be understood to encompass values close to those ranges or values. For ranges of values, between the endpoints of each of the ranges and the individual points, and between the individual points may be combined with each other to give one or more new ranges of values, and these ranges of values should be considered as specifically disclosed herein.
The invention provides a fluid loss additive composition, which comprises a main fluid loss additive and a fluid loss additive, wherein the main fluid loss additive is a cellulose graft copolymer, and the fluid loss additive is at least one selected from polymer fluid loss additives GDK, low-viscosity fluid loss additives SDDJ-3, fluid loss additives Redu1, temperature-resistant and salt-resistant fluid loss additives SDKJ-2 and silicon fluoride fluid loss additives GF;
the cellulose graft copolymer comprises a carboxymethyl cellulose main chain and a side chain, wherein the side chain comprises a structural unit shown in a formula (1), a structural unit shown in a formula (2) and a structural unit shown in a formula (3);
the mass ratio of the main chain of the carboxymethyl cellulose to the structural unit shown in the formula (1), the structural unit shown in the formula (2) and the structural unit shown in the formula (3) is (2-6): (1-4): (1-3): 1;
the mass ratio of the main filtrate reducer to the auxiliary filtrate reducer is (0.1-3) to 1.
Preferably, the mass ratio of the main chain of the carboxymethyl fiber to the structural unit represented by formula (1), the structural unit represented by formula (2) and the structural unit represented by formula (3) is (2-6): (2-4): (1-3): 1, more preferably (2-6): (2-3): (1-2): 1.
preferably, the cellulose graft copolymer has a viscosity average molecular weight of 200 to 300 ten thousand.
In the present invention, it is preferable that the cellulose graft copolymer is prepared by a preparation method comprising the steps of: under the protection of inert gas and in the presence of an initiator, carrying out graft copolymerization on carboxymethyl cellulose (CMC) and a monomer mixture in water to obtain a polymer solution containing the cellulose graft copolymer; wherein the monomer mixture comprises: acrylamide (AM), 2-methyl-2-acrylamidopropanesulfonic Acid (AMPS), and methacryloyloxyethyltrimethyl ammonium chloride (METAC).
The mass ratio of the dosage of the carboxymethyl cellulose, the acrylamide, the 2-methyl-2-acrylamido propanesulfonic acid and the methacryloyloxyethyl trimethyl ammonium chloride is (2-6): (1-4): (1-3): 1. preferably, the mass ratio of the dosage of the carboxymethyl cellulose, the acrylamide, the 2-methyl-2-acrylamido propanesulfonic acid and the methacryloyloxyethyl trimethyl ammonium chloride is (2-6): (2-4): (1-3): 1, more preferably (2-6): (2-3): (1-2): 1.
preferably, the initiator is a redox initiator consisting of persulfate and a reducing agent or a cerium ion initiator, and more preferably a cerium ion initiator.
Preferably, the initiator is used in an amount of 0.1 to 0.5 wt%, preferably 0.2 to 0.4 wt%, based on the amount of carboxymethyl cellulose.
Preferably, the conditions of the graft copolymerization reaction include: the reaction temperature is 35-60 ℃, the reaction time is 2-8h, and the pH value is 3-11. Further preferably, the reaction temperature is 45-55 ℃, the reaction time is 3.5-5h, and the pH value is 5-8.
In the present invention, the fluid loss additives are all commercially available. Preferably, the fluid loss additive is a fluid loss additive Redu1 and/or a temperature and salt resistant fluid loss additive SDKJ-2.
Preferably, the mass ratio of the main fluid loss additive to the fluid loss additive is (0.7-2.6): 1.
In a second aspect, the present invention provides the use of a fluid loss additive composition according to the first aspect of the present invention in a water-based drilling fluid.
In the invention, the main fluid loss additive and the auxiliary fluid loss additive are used in a matched manner, so that the temperature resistance, salt resistance, calcium resistance and poor soil resistance, the fluid loss reduction capability, the lubricating performance and the sedimentation stability of the water-based drilling fluid can be effectively improved.
In a third aspect, the invention provides a water-based drilling fluid comprising water, a fluid loss additive composition according to the first aspect of the invention, a viscosifying agent, a plugging and sloughing inhibitor, a lubricant, clay and weighting agent, and optionally a shale inhibitor.
In the present invention, the tackifier, the plugging and anti-collapse agent, the lubricant, the clay and the weighting agent are all commercially available, and the content of the clay and the weighting agent can be adjusted according to the prior art. Wherein, the clay can be bentonite, and the weighting agent can be barite.
Preferably, the tackifier is selected from at least one of polyacrylamide, polyaluminium chloride, hydroxypropyl methylcellulose, hydroxyethyl cellulose and natural polymer tackifier IND 30. More preferably polyacrylamide and/or natural polymer tackifier IND 30.
Preferably, the plugging and anti-collapse agent is selected from at least one of a bionic plugging agent FS-FDJ, a water-dispersible emulsified asphalt powder SFT, a non-fluorescent white asphalt NFA-25 as an anti-collapse agent and a low-fluorescent sulfonated asphalt DYFT-3, and is more preferably the water-dispersible emulsified asphalt powder SFT and/or the non-fluorescent white asphalt NFA-25 as the anti-collapse agent.
Preferably, the lubricant is selected from at least one of graphite lubricant GD-2, solid polymer alcohol PGCS-1 of the inhibited lubricant, vegetable oil ester lubricant LUBE, water-based lubricant GreenLube and nano emulsified paraffin SDEP-2, and more preferably solid polymer alcohol PGCS-1 of the inhibited lubricant and/or vegetable oil ester lubricant LUBE.
According to the invention, the shale inhibitor can be at least one of a shale inhibitor poly-silicon JW-1, aminopolyol AP-1 and an environment-friendly blocking and anti-collapse agent ZDEA-3. The aqueous based drilling fluid may be free of the shale inhibitor, for example, when the viscosifier is polyacrylamide and/or natural polymer viscosifier IND30, or the lubricant is a solid polyalcohol inhibiting PGCS-1 lubricant.
In the present invention, preferably, the fluid loss additive composition is contained in an amount of 0.5 to 3 parts by weight, wherein the main fluid loss additive may be contained in an amount of 0.3 to 0.8 part by weight, and the fluid loss additive may be contained in an amount of 0.3 to 0.8 part by weight, relative to 100 parts by weight of water; the content of the tackifier is 0.1-1 part by weight; the content of the plugging anti-collapse agent is 1-3 parts by weight; the content of the lubricant is 1-3 parts by weight. More preferably, the fluid loss additive composition is present in an amount of 1 to 1.5 parts by weight; the content of the tackifier is 0.1-0.2 weight part; the content of the plugging anti-collapse agent is 2-3 parts by weight; the content of the lubricant is 2-3 parts by weight.
According to a preferred embodiment, the water-based drilling fluid contains a primary fluid loss additive, a fluid loss additive, water, bentonite, barite, a tackifier, a plugging anti-collapse agent and a lubricant; relative to 100 parts by weight of water, the content of the tackifier is 0.1-0.2 part by weight, the content of the plugging anti-collapse agent is 2-3 parts by weight, and the content of the lubricant is 2-3 parts by weight; the content of the bentonite is 3-5 parts by weight; the barite is used in an amount such that the density of the water-based drilling fluid is 1-2.6g/cm3。
In this specific embodiment, the primary fluid loss additive is a cellulose graft copolymer comprising a carboxymethyl cellulose backbone and a side chain comprising a structural unit represented by formula (1), a structural unit represented by formula (2), and a structural unit represented by formula (3);
the mass ratio of the main chain of the carboxymethyl cellulose to the structural unit shown in the formula (1), the structural unit shown in the formula (2) and the structural unit shown in the formula (3) is (2-6): (2-3): (1-2): 1; the cellulose graft copolymer has a viscosity average molecular weight of 200 to 300 ten thousand.
In this particular embodiment, the fluid loss additive is Redu1 and/or SDKJ-2; the tackifier is polyacrylamide and/or a natural polymer tackifier IND 30; the plugging anti-collapse agent is water-dispersed emulsified asphalt powder SFT and/or non-fluorescent white asphalt NFA-25 serving as an anti-collapse agent; the lubricant is solid polyalcohol PGCS-1 inhibiting lubricant and/or vegetable oil ester lubricant LUBE. The inventor finds in research that the water-based drilling fluid adopting the formula has optimal temperature resistance, salt resistance, calcium resistance, poor soil resistance, fluid loss reduction capability, lubricating performance and sedimentation stability.
In a fourth aspect, the invention provides the use of the water-based drilling fluid of the third aspect of the invention in oil recovery in an oil field. The water-based drilling fluid provided by the invention has good temperature resistance, salt resistance, calcium resistance and poor soil resistance, good fluid loss reduction capability, good lubricating property and good sedimentation stability, can meet the requirement of environmental protection, and can be applied to complex stratum oil field exploitation.
The present invention will be described in detail below by way of examples. In the following examples, various raw materials used are commercially available without specific description.
Fluid loss additive Redu1 was purchased from Beijing Pekangkai technical development Co., Ltd;
the natural polymer tackifier IND30 is purchased from Beijing Pekangjia technical development Co., Ltd;
polyacrylamide PAM was purchased from zentai chemical ltd, yohimu;
the anti-collapse agent non-fluorescent white asphalt NFA-25 is purchased from Beijing Pekangjia technical development Co., Ltd;
the water dispersible emulsified asphalt powder SFT is purchased from Hebei Guangdong petrochemical company Limited;
the solid polyalcohol PGCS-1 for inhibiting the lubricant is purchased from Beijing Pekangkangjia technical development Co., Ltd;
vegetable oil ester lubricants, LUBE, were purchased from Tianjin Zhonghai oil clothing chemical Co.
Viscosity average molecular weightAccording to the empirical formula M of Mark-Houwink, 802[ eta [ ]]125Calculating to obtain; wherein eta is intrinsic viscosity, and is measured by dilution method.
Preparation example 1
1) Adding deionized water into a four-neck flask placed in a water bath, adding CMC under the protection of nitrogen, heating to 45 ℃, and stirring at constant temperature for 30 min;
2) adding 30 weight percent NaOH solution into a four-neck flask, and adjusting the pH value to 7;
3) adding the aqueous solution of ammonium ceric nitrate into a four-neck flask, and stirring for 10min at constant temperature;
4) respectively adding the AM aqueous solution, the AMPS aqueous solution and the METAC aqueous solution into a four-neck flask, continuously introducing nitrogen, and reacting at constant temperature for 4 hours;
wherein the mass ratio of the water consumption to the total amount of the polymerization monomers is 100: 6, CMC: AM: AMPS: METAC with the mass ratio of 4:2:1:1, wherein the dosage of the ammonium ceric nitrate is 0.3 percent of the CMC by weight;
5) after the reaction is finished, washing the obtained polymer solution with ethanol, carrying out vacuum filtration and repeated washing with deionized water, and drying in an oven at 60 ℃ to constant weight to obtain a crude product of the graft copolymer;
6) the crude product was extracted with acetone in a soxhlet extractor for 12 hours to remove the homopolymer and finally the residue was dried in vacuo at 70 ℃ for 4 hours to give a cellulose graft copolymer, designated a 1. The viscosity average molecular weight was found to be 269 ten thousand.
FIG. 1 is an IR spectrum of carboxymethylcellulose and FIG. 2 is an IR spectrum of cellulose graft copolymer A1; in FIG. 1, 3413.44cm-1Is a hydroxyl stretching vibration absorption peak on the CMC ring; 2923.61cm-1Is long-chain methylene-CH2-a characteristic absorption peak; at 1619.94cm-1And 1423.23cm-1A characteristic absorption peak for C ═ O for the carboxylate; 1328.74cm-1C-H bending vibration of glucose ring; 1110.82cm-1Is a C-O-C stretching vibration peak of a cyclic ether structure; 1058.75cm-1Is a characteristic absorption peak of the cellulose ether beta- (1,4) -glycosidic bond; compared with fig. 1, the infrared spectrum of fig. 2 is newly added: 3205.16cm-1Expansion and contraction of amide group in amideA vibration peak; 1634.15cm-1Stretching vibration peak of primary amine group in amide; at 1731.79cm-1C ═ O shock absorption peaks ascribed to the METAC structural units also appear; 1197.11cm-1And 1036.91cm-1And 953.15cm-1Shows graft-induced SO3 2-Characteristic absorption peak of (1).
As can be seen, the infrared spectrogram of the cellulose graft copolymer A1 shows characteristic absorption peaks of carboxymethyl cellulose, acrylamide, 2-acrylamido-methylpropanesulfonic acid and methacryloyloxyethyl trimethyl ammonium chloride, thereby indicating that the three monomers and the carboxymethyl cellulose have graft copolymerization reaction, and the synthesized carboxymethyl cellulose graft acrylamide-2-acrylamido-methylpropanesulfonic acid-methacryloyloxyethyl trimethyl ammonium chloride polymer can be concluded to be obtained.
Preparation example 2
The preparation was carried out as in preparation example 1, except that the CMC: AM: AMPS: METAC mass 6:3:2:1, a cellulose graft copolymer was obtained, noted A2. The viscosity average molecular weight was measured to be 285 ten thousand.
Preparation example 3
The preparation was carried out as in preparation example 1, except that the CMC: AM: AMPS: METAC mass 3:1:1:1, a cellulose graft copolymer was obtained, noted A3. The viscosity average molecular weight was found to be 253 ten thousand.
Comparative preparation example 1
The procedure of preparation 1 is followed, except that the monomer used is replaced by AM in an amount equal to the sum of the masses of AM, AMPS and METAC; a cellulose graft copolymer was obtained, denoted B1. The viscosity average molecular weight was measured to be 211 ten thousand.
Comparative preparation example 2
The procedure of preparation example 1 was followed, except that the monomers used were replaced with AMPS in an amount equal to the sum of the masses of AM, AMPS and METAC; a cellulose graft copolymer was obtained, denoted B2. The viscosity average molecular weight was measured to be 223 ten thousand.
Comparative preparation example 3
The procedure of preparation 1 is followed, except that the monomers used are replaced by METAC in an amount equal to the sum of the masses of AM, AMPS and METAC; a cellulose graft copolymer was obtained, denoted B3. The viscosity average molecular weight was found to be 236 ten thousand.
Example 1
Adding 16g of Weichai Na soil (purchased from Weichai Fang bentonite factory) and 0.8g of Na into 400mL of deionized water2CO3Pre-hydrating for 24h to obtain bentonite-based slurry, sequentially adding cellulose graft copolymer A1, filtrate reducer Redu1, natural polymer tackifier IND30, anti-collapse agent non-fluorescent white asphalt NFA-25 and lubricant inhibiting solid polymer alcohol PGCS-1 to make their addition amount meet the content in Table 1, and adding barite to weight 1.2g/cm3And obtaining the water-based drilling fluid which is marked as Z1.
Examples 2 to 7
The procedure is followed as in example 1, except that the type and amount of the components are adjusted, as shown in Table 1, to obtain water-based drilling fluids Z2-Z7.
Comparative examples 1 to 3
The procedure of example 1 was followed except that the types and amounts of the components were adjusted as shown in Table 1 to obtain water-based drilling fluids D1-D3.
TABLE 1
Note: the content means the weight part contained with respect to 100 weight parts of water.
Test examples 1 to 4
The rheological properties were characterized by Apparent Viscosity (AV), Plastic Viscosity (PV), and dynamic shear force (YP) measured by a six-speed rotational viscometer (model ZNN-D6S, Qingdao dream Instrument Co., Ltd.).
API filtration loss FLAPIBy medium pressure fluid loss apparatus (SD-4, Qingdao dream apparatus Co., Ltd.).
HTHP filtrate loss FLHTHPMeasured by a high-temperature high-pressure filtration loss instrument (GGS42, Haitoda instruments, Qingdao) under the test conditions of 140 ℃ and 3.5 MPa.
The sedimentation stability is evaluated by the density difference of the upper layer and the lower layer after the water-based drilling fluid is settled for 24 hours at the temperature of 25 ℃ under the atmospheric pressure condition, the density is measured by a drilling fluid densimeter instrument (Qingdao Haitoda company),
the sticking coefficient was measured by a mud cake sticking coefficient measuring instrument (GNF-2, Qingdao and Chunjun drilling fluid Instrument Co., Ltd.).
The lubricity coefficient was measured by an EP-B extreme pressure lubricator (Qingdao Haitoda instruments Co.).
Test example 1
The water-based drilling fluids obtained in the examples and the comparative examples are aged for 16h at 140 ℃, the rheological properties of the water-based drilling fluids before and after aging are analyzed at room temperature (25 ℃), and the filtration loss FL is determinedAPI。
Determination of FL of Water-based drilling fluid before agingHTHPAdhesion coefficient, lubrication coefficient, sedimentation stability.
The above basic performance evaluation results for water-based drilling fluids are shown in table 2.
TABLE 2
As can be seen from the data in Table 2, the water-based drilling fluid provided by the invention can keep lower fluid loss after being aged for 16 hours at 140 ℃, has better fluid loss reduction effect, and has better lubricating property and sedimentation stability.
As can be seen by comparing example 1 with example 6, the mass ratio of the amounts of carboxymethyl cellulose, acrylamide, 2-methyl-2-acrylamidopropanesulfonic acid and methacryloyloxyethyltrimethyl ammonium chloride used in the preparation of carboxymethyl cellulose is defined as (2-6): (2-3): (1-2): 1, the filtration loss of the water-based drilling fluid after being aged for 16 hours at 140 ℃ can be further reduced, the sedimentation stability of the water-based drilling fluid is improved, and the comprehensive performance of the water-based drilling fluid is better.
By comparing the example 1 with the example 7, the mass content ratio of the main filtrate reducer to the auxiliary filtrate reducer is limited to (0.7-2.6):1, so that the filtrate loss of the water-based drilling fluid after being aged for 16 hours at 140 ℃ can be further reduced, the stability of the water-based drilling fluid is improved, and the comprehensive performance of the water-based drilling fluid is better.
Test example 2
Adding 2 parts by weight of CaCl into water-based drilling fluid2Aging at 140 deg.C for 16h, respectively at room temperature (25 deg.C), analyzing rheological properties of the water-based drilling fluid before and after aging, and determining its fluid loss FLAPIThe results are shown in Table 3.
TABLE 3
As can be seen from the data in Table 3, the water-based drilling fluid provided by the invention has better calcium pollution resistance.
Test example 3
Adding 20 parts by weight of NaCl into the water-based drilling fluid, aging for 16h at 140 ℃, respectively carrying out rheological property analysis on the water-based drilling fluid before and after aging at room temperature (25 ℃), and measuring the filtration loss FLAPIThe results are shown in Table 4.
TABLE 4
As can be seen from the data in Table 4, the water-based drilling fluid provided by the invention has better salt resistance.
Test example 4
Adding 8 parts by weight of inferior soil into the water-based drilling fluid, aging for 16h at 140 ℃, respectively carrying out rheological property analysis on the water-based drilling fluid before and after aging at room temperature (25 ℃), and measuring the filtration loss FLAPIThe results are shown in Table 5.
TABLE 5
As can be seen from the data in Table 5, the water-based drilling fluid provided by the invention has better resistance to the poor soil.
Test example 5
The test example is used for testing the environmental protection property of the water-based drilling fluid.
The colour strength was measured according to the method of GB16783.1-2014 (oil and gas industry drilling fluid field test part 1: water-based drilling fluid).
Turbidity was measured by the method according to GB16783.1-2014 (oil and gas industry drilling fluid field test part 1: water-based drilling fluid).
The pH was measured by the method according to GB16783.1-2014 (oil and gas industry drilling fluid field test part 1: water-based drilling fluid).
The degree of mineralization was measured by the method according to GB16783.1-2014 (oil and gas industry drilling fluid field test part 1: water-based drilling fluid).
Hardness was measured by the method according to GB16783.1-2014 (oil and gas industry drilling fluid field test part 1: water-based drilling fluid).
The calcium ion content was determined by the method according to GB16783.1-2014 (oil and gas industry drilling fluid field test part 1: water-based drilling fluid).
The results of the above tests are shown in Table 6.
Chemical Oxygen Demand (COD) was measured by a chemical oxygen demand (model HH-6, Jiangsu electric analyzer factory) with reference to GB11914-89, dichromate determination for chemical oxygen demand of Water.
Biological Oxygen Demand (BOD)5) Refer to HJ05-2009 Water quality five days Biochemical Oxygen Demand (BOD)5) The determination of (1) dilution and inoculation method (determination, measured by a digital BOD determinator (model 880, Jiangsu electric Analyzer Co., Ltd.).
Biotoxicity (EC)50) The determination was carried out according to ASTM D5660-96 Standard test method for microbial toxicity in the luminescent Marine bacterial toxicity test method.
The results of the above tests are shown in Table 7.
TABLE 6
TABLE 7
As can be seen from the data in tables 6 and 7, the water-based drilling fluid provided by the invention has better environmental protection performance.
The preferred embodiments of the present invention have been described above in detail, but the present invention is not limited thereto. Within the scope of the technical idea of the invention, many simple modifications can be made to the technical solution of the invention, including combinations of various technical features in any other suitable way, and these simple modifications and combinations should also be regarded as the disclosure of the invention, and all fall within the scope of the invention.
Claims (24)
1. A fluid loss additive composition comprises a main fluid loss additive and a fluid loss additive, wherein the main fluid loss additive is a cellulose graft copolymer, and the fluid loss additive is a fluid loss additive Redu1 and/or a silicon fluorine fluid loss additive GF;
the cellulose graft copolymer comprises a carboxymethyl cellulose main chain and a side chain, wherein the side chain comprises a structural unit shown in a formula (1), a structural unit shown in a formula (2) and a structural unit shown in a formula (3);
the mass ratio of the main chain of the carboxymethyl cellulose to the structural unit shown in the formula (1), the structural unit shown in the formula (2) and the structural unit shown in the formula (3) is (2-6): (1-4): (1-3): 1;
the mass ratio of the main filtrate reducer to the auxiliary filtrate reducer is (0.1-3) to 1.
2. The fluid loss additive composition according to claim 1, wherein the mass ratio of the carboxymethyl cellulose main chain to the structural unit represented by formula (1), the structural unit represented by formula (2), and the structural unit represented by formula (3) is (2-6): (2-3): (1-2): 1.
3. the fluid loss additive composition of claim 1, wherein the cellulose graft copolymer has a viscosity average molecular weight of from 200 to 300 ten thousand.
4. The fluid loss additive composition of claim 1, wherein the cellulose graft copolymer is prepared by a preparation method comprising the steps of:
under the protection of inert gas and in the presence of an initiator, carrying out graft copolymerization on a mixture of carboxymethyl cellulose and a monomer in water to obtain a polymer solution containing the cellulose graft copolymer; wherein the monomer mixture comprises: acrylamide, 2-methyl-2-acrylamidopropanesulfonic acid, and methacryloyloxyethyltrimethylammonium chloride.
5. The fluid loss additive composition of claim 4, wherein the initiator is a redox initiator comprising a persulfate salt and a reducing agent or a cerium ion initiator.
6. The fluid loss additive composition of claim 4, wherein the initiator is a cerium ion initiator.
7. The fluid loss additive composition of claim 4, wherein the initiator is present in an amount of from 0.1 to 0.5 weight percent, based on the amount of carboxymethyl cellulose.
8. The fluid loss additive composition of claim 4, wherein the initiator is present in an amount of from 0.2 to 0.4 weight percent, based on the amount of carboxymethyl cellulose.
9. The fluid loss additive composition of claim 4, wherein the conditions of the graft copolymerization reaction comprise: the reaction temperature is 35-60 ℃; the reaction time is 2-8 h; the pH value is 3-11.
10. The fluid loss additive composition of claim 9, wherein the reaction temperature is 45-55 ℃.
11. The fluid loss additive composition of claim 9, wherein the reaction time is from 3.5 to 5 hours.
12. The fluid loss additive composition of claim 9, wherein the pH is from 5 to 8.
13. The fluid loss additive composition of any of claims 1-12, wherein the fluid loss additive is fluid loss additive Redu 1.
14. The fluid loss additive composition of any of claims 1-12, wherein the mass ratio of primary fluid loss additive to fluid loss additive is (0.7-2.6): 1.
15. Use of a fluid loss additive composition according to any of claims 1-14 in a water-based drilling fluid.
16. A water-based drilling fluid comprising water, a fluid loss additive composition according to any one of claims 1 to 14, a viscosifying agent, a plugging anti-sloughing agent, a lubricant, clay and a weighting agent.
17. The water-based drilling fluid of claim 16, wherein the water-based drilling fluid further comprises a shale inhibitor.
18. The water-based drilling fluid of claim 16 or 17, wherein the viscosifier is selected from at least one of polyacrylamide, polyaluminium chloride, hydroxypropyl methylcellulose, hydroxyethyl cellulose, and natural polymer viscosifier IND 30.
19. The water-based drilling fluid of claim 16 or 17, wherein the viscosifier is polyacrylamide and/or natural polymer viscosifier IND 30.
20. The water-based drilling fluid of claim 16 or 17, wherein the plugging and anti-sloughing agent is water-dispersed emulsified asphalt powder (SFT) and/or a non-fluorescent white asphalt (NFA-25) inhibitor.
21. The water-based drilling fluid of claim 16 or 17, wherein the lubricant is selected from at least one of graphite lubricant GD-2, inhibited lubricant solid polymeric alcohol PGCS-1, vegetable oil ester lubricant LUBE, and water-based lubricant GreenLube.
22. The water-based drilling fluid of claim 16 or 17, wherein the lubricant is a solid lubricant inhibiting polyalcohol PGCS-1 and/or a vegetable oil ester lubricant LUBE.
23. The water-based drilling fluid according to claim 16 or 17, wherein the fluid loss additive composition is present in an amount of 0.5 to 3 parts by weight, the viscosifier is present in an amount of 0.1 to 1 part by weight, the plugging and anti-sloughing agent is present in an amount of 1 to 3 parts by weight, and the lubricant is present in an amount of 1 to 3 parts by weight, relative to 100 parts by weight of water.
24. Use of the water-based drilling fluid according to any one of claims 16 to 23 for oil recovery in oil fields.
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